Approval and Promulgation of Air Quality Implementation Plans; State of Arkansas; Regional Haze and Interstate Visibility Transport Federal Implementation Plan Revisions; Withdrawal of Federal Implementation Plan for NOX, 5915-5920 [2018-02145]

Download as PDF Federal Register / Vol. 83, No. 29 / Monday, February 12, 2018 / Rules and Regulations Airplanes, Attention: Contractual & Data Services (C&DS), 2600 Westminster Blvd., MC 110–SK57, Seal Beach, CA 90740–5600; telephone 562–797–1717; internet https:// www.myboeingfleet.com. (4) You may view this service information at the FAA, Transport Standards Branch, 1601 Lind Avenue SW, Renton, WA. For information on the availability of this material at the FAA, call 425–227–1221. (5) You may view this service information that is incorporated by reference at the National Archives and Records Administration (NARA). For information on the availability of this material at NARA, call 202–741–6030, or go to: https:// www.archives.gov/federal-register/cfr/ibrlocations.html. Issued in Renton, Washington, on January 26, 2018. Michael Kaszycki, Acting Director, System Oversight Division, Aircraft Certification Service. [FR Doc. 2018–02358 Filed 2–9–18; 8:45 am] BILLING CODE 4910–13–P ENVIRONMENTAL PROTECTION AGENCY 40 CFR Part 52 [EPA–R06–OAR–2015–0189; FRL–9973–61– OAR] Approval and Promulgation of Air Quality Implementation Plans; State of Arkansas; Regional Haze and Interstate Visibility Transport Federal Implementation Plan Revisions; Withdrawal of Federal Implementation Plan for NOX for Electric Generating Units in Arkansas Environmental Protection Agency (EPA). ACTION: Final rule. AGENCY: The Environmental Protection Agency (EPA) is amending a Federal Implementation Plan (FIP) that addresses regional haze for the first planning period for Arkansas that was published in the Federal Register on September 27, 2016, as it applies to the nitrogen oxide (NOX) requirements for the Arkansas Electric Cooperative Corporation (AECC) Bailey Plant Unit 1; AECC McClellan Plant Unit 1; the American Electric Power/Southwestern Electric Power Company (AEP/ SWEPCO) Flint Creek Plant Boiler No. 1; Entergy Arkansas, Inc. (Entergy) Lake Catherine Plant Unit 4; Entergy White Bluff Plant Units 1 and 2 and the Auxiliary Boiler; and Entergy Independence Plant Units 1 and 2. We are removing these FIP requirements because in a separate action being published in this Federal Register, we are taking final action to approve daltland on DSKBBV9HB2PROD with RULES SUMMARY: VerDate Sep<11>2014 18:49 Feb 09, 2018 Jkt 244001 revisions to the Arkansas State Implementation Plan (SIP) submitted by the State of Arkansas through the Arkansas Department of Environmental Quality (ADEQ) on October 31, 2017, that address NOX requirements for the nine aforementioned units. DATES: This final rule will be effective March 14, 2018. ADDRESSES: The EPA has established a docket for this action under Docket No. EPA–R06–OAR–2015–0189. All documents in the dockets are listed on the https://www.regulations.gov website. Although listed in the index, some information is not publicly available, e.g., Confidential Business Information or other information whose disclosure is restricted by statute. Certain other material, such as copyrighted material, is not placed on the internet and will be publicly available only in hard copy form. Publicly available docket materials are available either electronically through https:// www.regulations.gov or in hard copy at the EPA Region 6, 1445 Ross Avenue, Suite 700, Dallas, Texas 75202–2733. FOR FURTHER INFORMATION CONTACT: Dayana Medina, (214) 665–7241; medina.dayana@epa.gov. SUPPLEMENTARY INFORMATION: Throughout this document wherever ‘‘we,’’ ‘‘us,’’ or ‘‘our’’ is used, we mean the EPA. Table of Contents I. What is the background for this action? II. What final action is EPA taking? III. Responses to Comments Received IV. Statutory and Executive Order Reviews I. What is the background for this action? Arkansas submitted a SIP revision on September 9, 2008, to address the first regional haze implementation period. On August 3, 2010, Arkansas submitted a SIP revision with non-substantive revisions to the Arkansas Pollution Control and Ecology Commission (APCEC) Regulation 19, Chapter 15; this Chapter identified the BART-eligible and subject-to-BART sources in Arkansas and established the BART emission limits for subject-to-BART sources. On September 27, 2011, the State submitted supplemental information to address the regional haze requirements. We are hereafter referring to these regional haze submittals collectively as the ‘‘2008 Arkansas Regional Haze SIP.’’ On March 12, 2012, we partially approved and partially disapproved the 2008 Arkansas Regional Haze SIP.1 On September 27, 2016, we published a FIP (the Arkansas 1 77 PO 00000 FR 14604. Frm 00045 Fmt 4700 Sfmt 4700 5915 Regional Haze FIP) addressing the disapproved portions of the 2008 Arkansas Regional Haze SIP.2 Among other things, the FIP established NOX emission limits under the BART requirements for Bailey Unit 1; McClellan Unit 1; Flint Creek Boiler No. 1; Lake Catherine Unit 4; and White Bluff Units 1 and 2 and the Auxiliary Boiler. The FIP also established NOX emission limits under the reasonable progress requirements for Independence Units 1 and 2. In response to petitions submitted by the State of Arkansas and industry parties seeking reconsideration and an administrative stay of the final Arkansas Regional Haze FIP,3 in a letter dated April 14, 2017, we announced the convening of a proceeding to reconsider several elements of the FIP, including the appropriate compliance dates for the NOX emission limits for Flint Creek Unit 1, White Bluff Units 1 and 2, and Independence Units 1 and 2.4 EPA also published a document in the Federal Register on April 25, 2017, administratively staying the effectiveness of the 18-month NOX compliance dates in the FIP for these units for a period of 90 days.5 On July 13, 2017, the EPA published a proposed rule that would extend the FIP’s NOX compliance dates for Flint Creek Unit 1, White Bluff Units 1 and 2, and Independence Units 1 and 2, by 21 months to January 27, 2020.6 7 On July 12, 2017, Arkansas submitted a proposed SIP revision with a request for parallel processing, addressing the NOX requirements for Bailey Unit 1, McClellan Unit 1, Flint Creek Boiler No. 1, Lake Catherine Unit 4, White Bluff Units 1 and 2 and the Auxiliary Boiler, and Independence Units 1 and 2 (Arkansas Regional Haze NOX SIP 2 81 FR 66332; see also 81 FR 68319 (October 4, 2016) (correction). 3 See the docket associated with this proposed rulemaking for a copy of the petitions for reconsideration and administrative stay submitted by the State of Arkansas; Entergy Arkansas Inc., Entergy Mississippi Inc., and Entergy Power LLC (collectively ‘‘Entergy’’); AECC; and the Energy and Environmental Alliance of Arkansas (EEAA). 4 Letter from E. Scott Pruitt, Administrator, EPA, to Nicholas Jacob Bronni & Jamie Leigh Ewing, Arkansas Attorney General’s Office, (April 14, 2017). A copy of this letter is included in the docket, https://www.regulations.gov/ document?D=EPA-R06-OAR-2015-0189-0240. 5 82 FR 18994. 6 82 FR 32284. 7 EPA has not finalized the July 13, 2017 proposed rule. The separate final action approving the Arkansas Regional Haze NOX SIP revision together with this final action EPA is taking to withdraw the source-specific NOX emission limits for the nine EGUs in the Arkansas Regional Haze FIP, make it unnecessary to finalize our July 13, 2017 proposed rule to revise the NOX compliance dates in the Arkansas Regional Haze FIP. E:\FR\FM\12FER1.SGM 12FER1 5916 Federal Register / Vol. 83, No. 29 / Monday, February 12, 2018 / Rules and Regulations daltland on DSKBBV9HB2PROD with RULES revision or Arkansas NOX SIP revision). Arkansas’ proposed July 2017 Regional Haze NOX SIP revision addressed the NOX BART requirements for Arkansas’ EGUs by relying on participation in the Cross State Air Pollution Rule (CSAPR) ozone season NOX trading program as an alternative to BART. The July 2017 Regional Haze NOX SIP revision proposal also made the determination that no additional NOX emission controls for Arkansas sources, beyond participation in CSAPR’s ozone season NOX trading program, are required for achieving reasonable progress in Arkansas. The July 2017 Regional Haze SIP revision addresses NOX requirements for the same EGUs for which we established source-specific NOX emission limits in the September 27, 2016 FIP. In a document published in the Federal Register on September 11, 2017, we proposed to approve the Arkansas Regional Haze NOX SIP revision and proposed to withdraw corresponding parts of the FIP.8 On October 31, 2017, we received ADEQ’s final NOX SIP revision addressing BART and reasonable progress requirements for NOX for EGUs in Arkansas for the first implementation period. In a final action being published separately in this Federal Register, we are taking final action to approve the Arkansas Regional Haze NOX SIP revision. The background for this final rule and the separate action also being published in this Federal Register that approves the Arkansas Regional Haze NOX SIP revision is also discussed in detail in our September 11, 2017 proposal.9 The comment period was open for 30 days, and we received comments from three commenters in response to our proposed action. II. What final action is EPA taking? We are withdrawing those portions of the Arkansas Regional Haze FIP at 40 CFR 52.173 that impose NOX requirements on Bailey Unit 1; McClellan Unit 1; Flint Creek Boiler No. 1; Lake Catherine Unit 4; White Bluff Units 1 and 2 and the Auxiliary Boiler; and Independence Units 1 and 2. Therefore, as of the effective date of this final rule, the Arkansas Regional Haze FIP NOX requirements will no longer apply to the nine aforementioned units. All other provisions of the Arkansas Regional Haze FIP are unaffected by this action and remain in place. As explained in our September 11, 2017 proposal,10 this action is made possible because of our separate action FR 42627. FR 42627. 10 82 FR 42627. being published in this Federal Register to approve the Arkansas Regional Haze NOX SIP revision submitted to us on July 12, 2017, with a request for parallel processing. On October 31, 2017, we received ADEQ’s final SIP revision addressing NOX BART for EGUs in Arkansas and the reasonable progress requirements for NOX for the first implementation period. The final Arkansas Regional Haze NOX SIP revision we received on October 31, 2017, did not contain significant changes from the state’s proposed SIP revision. Therefore, it is appropriate for us to take final action, as proposed, on the final SIP revision. EPA has made the determination that the Arkansas Regional Haze NOx SIP revision is approvable because the plan’s provisions meet all applicable requirements of the CAA and EPA implementing regulations. EPA is finalizing this action under section 110 and part C of the Act. III. Responses to Comments Received We received a total of three comment letters concerning our proposed action. The issues raised in those comment letters are summarized, along with our response to each, in the separate document being published in this Federal Register that approves the Arkansas Regional Haze NOX SIP revision. Copies of the comments are available in the docket for this rulemaking.11 V. Statutory and Executive Order Reviews Additional information about these statutes and Executive Orders can be found at https://www2.epa.gov/ lawsregulations/laws-and-executiveorders. A. Executive Order 12866: Regulatory Planning and Review and Executive Order 13563: Improving Regulation and Regulatory Review This action is not a significant regulatory action and was therefore not submitted to the Office of Management and Budget (OMB) for review. This final rule revises a FIP to withdraw sourcespecific NOX emission limits for only six facilities in Arkansas and is therefore not a rule of general applicability. B. Executive Order 13771: Reducing Regulations and Controlling Regulatory Costs This action is not an Executive Order 13771 regulatory action because this 8 82 9 82 VerDate Sep<11>2014 18:49 Feb 09, 2018 11 Please see Docket No. EPA–R06–OAR–2015– 0189 in the regulations.gov website. Jkt 244001 PO 00000 Frm 00046 Fmt 4700 Sfmt 4700 action is not significant under Executive Order 12866. C. Paperwork Reduction Act (PRA) This action does not impose an information collection burden under the provisions of the PRA. Burden is defined at 5 CFR 1320.3(b). This final rule revises a FIP to withdraw sourcespecific NOX emission limits for six facilities in Arkansas. D. Regulatory Flexibility Act (RFA) I certify that this final action will not have a significant economic impact on a substantial number of small entities under the RFA. This final action will not impose any requirements on small entities. This final action revises a FIP to withdraw source-specific NOX emission limits that apply to six power plants in Arkansas. E. Unfunded Mandates Reform Act (UMRA) This action does not contain any unfunded mandate as described in UMRA, 2 U.S.C. 1531–1538, and does not significantly or uniquely affect small governments. This action does not impose additional requirements beyond those imposed by state law. Accordingly, no additional costs to State, local, or tribal governments, or to the private sector, will result from this action. F. Executive Order 13132: Federalism This action does not have federalism implications. It will not have substantial direct effects on the states, on the relationship between the national government and the states, or on the distribution of power and responsibilities among the various levels of government. G. Executive Order 13175: Consultation and Coordination With Indian Tribal Governments This action does not have tribal implications, as specified in Executive Order 13175, because this partial FIP withdrawal does not apply on any Indian reservation land or in any other area where the EPA or an Indian tribe has demonstrated that a tribe has jurisdiction, and will not impose substantial direct costs on tribal governments or preempt tribal law. This final action revises a FIP to withdraw source-specific NOX emission limits that apply to six power plants in Arkansas. There are no Indian reservation lands in Arkansas. Thus, Executive Order 13175 does not apply to this action. E:\FR\FM\12FER1.SGM 12FER1 5917 Federal Register / Vol. 83, No. 29 / Monday, February 12, 2018 / Rules and Regulations H. Executive Order 13045: Protection of Children From Environmental Health Risks and Safety Risks The EPA interprets Executive Order 13045 as applying only to those regulatory actions that concern environmental health or safety risks that the EPA has reason to believe may disproportionately affect children, per the definition of ‘‘covered regulatory action’’ in section 2–202 of the Executive Order. This action is not subject to Executive Order 13045 because it does not concern an environmental health risk or safety risk. I. Executive Order 13211: Actions That Significantly Affect Energy Supply, Distribution, or Use This action is not subject to Executive Order 13211, because it is not a significant regulatory action under Executive Order 12866. J. National Technology Transfer and Advancement Act (NTTAA) This rulemaking does not involve technical standards. K. Executive Order 12898: Federal Actions To Address Environmental Justice in Minority Populations and Low-Income Populations The EPA believes the human health or environmental risk addressed by this action will not have potentially disproportionately high and adverse human health or environmental effects on minority, low-income or indigenous populations. L. Determination Under Section 307(d) Pursuant to CAA section 307(d)(1)(B), this action is subject to the requirements of CAA section 307(d), as it revises a FIP under CAA section 110(c). M. Congressional Review Act (CRA) This rule is exempt from the CRA because it is a rule of particular applicably. EPA is not required to submit a rule report regarding this action under section 801 because this is a rule of particular applicability that only affects six facilities in Arkansas. N. Petitions for Judicial Review Reporting and recordkeeping requirements, Visibility. Dated: January 25, 2018. E. Scott Pruitt, Administrator. Title 40, chapter I, of the Code of Federal Regulations is amended as follows: PART 52—APPROVAL AND PROMULGATION OF IMPLEMENTATION PLANS 1. The authority citation for part 52 continues to read as follows: ■ Authority: 42 U.S.C. 7401 et seq. Under section 307(b)(1) of the Clean Air Act, petitions for judicial review of this action must be filed in the United States Court of Appeals for the appropriate circuit by April 13, 2018. Filing a petition for reconsideration by the Administrator of this final rule does not affect the finality of this rule for the purposes of judicial review nor does it extend the time within which a petition for judicial review may be filed, and shall not postpone the effectiveness of such rule or action. This action may not be challenged later in proceedings to enforce its requirements (see section 307(b)(2)). Subpart E—Arkansas 2. Section 52.173 is amended by: a. Revising paragraphs (c)(3) through (10) and (12); ■ b. Removing paragraphs (c)(13) and (14); ■ c. Redesignating paragraphs (c)(15) through (29) as paragraphs (c)(13) through (27); and ■ d. Revising newly redesignated paragraphs (c)(14), (15), (17), (18), and (20) through (24). The revisions read as follows: ■ ■ § 52.173 Visibility protection. * List of Subjects in 40 CFR Part 52 Air pollution control, Best available retrofit technology, Environmental protection, Incorporation by reference, Intergovernmental relations, Nitrogen dioxide, Ozone, Regional haze, * * * * (c) * * * (3) Emissions limitations for AECC Bailey Unit 1 and AECC McClellan Unit 1. The individual SO2 and PM emission limits for each unit are as listed in the table in this paragraph (c)(3). Unit SO2 emission limit PM emission limit AECC Bailey Unit 1 ................... Use of fuel with a sulfur content limit of 0.5% by weight. Use of fuel with a sulfur content limit of 0.5% by weight. Use of fuel with a sulfur content limit of 0.5% by weight. Use of fuel with a sulfur content limit of 0.5% by weight. daltland on DSKBBV9HB2PROD with RULES AECC McClellan Unit 1 ............. (4) Compliance dates for AECC Bailey Unit 1 and AECC McClellan Unit 1. The owner or operator of each unit must comply with the SO2 and PM requirements listed in paragraph (c)(3) of this section by October 27, 2021. As of October 27, 2016, the owner or operator of each unit shall not purchase fuel for combustion at the unit that does not meet the sulfur content limit in paragraph (c)(3) of this section. The owner or operator of each unit must comply with the requirement in paragraph (c)(3) of this section to burn only fuel with a sulfur content limit of 0.5% by weight by October 27, 2021. (5) Compliance determination and reporting and recordkeeping requirements for AECC Bailey Unit 1 VerDate Sep<11>2014 18:49 Feb 09, 2018 Jkt 244001 and AECC McClellan Unit 1 for SO4 and PM. To determine compliance with the SO2 and PM requirements listed in paragraph (c)(3) of this section, the owner or operator shall sample and analyze each shipment of fuel to determine the sulfur content by weight, except for natural gas shipments. A ‘‘shipment’’ is considered delivery of the entire amount of each order of fuel purchased. Fuel sampling and analysis may be performed by the owner or operator of an affected unit, an outside laboratory, or a fuel supplier. All records pertaining to the sampling of each shipment of fuel as described in this paragraph (c)(5), including the results of the sulfur content analysis, must be maintained by the owner or PO 00000 Frm 00047 Fmt 4700 Sfmt 4700 operator and made available upon request to EPA and ADEQ representatives. (6) Emissions limitations for AEP Flint Creek Unit 1 and Entergy White Bluff Units 1 and 2. The individual SO2 emission limits for each unit are as listed in the table in this paragraph (c)(6), as specified in pounds per million British thermal units (lb/ MMBtu). The SO2 emission limits of 0.06 lb/MMBtu are on a rolling 30 boiler-operating-day averaging period. Unit AEP Flint Creek Unit 1 ......... Entergy White Bluff Unit 1 .... E:\FR\FM\12FER1.SGM 12FER1 SO2 emission limit (lb/MMBtu) 0.06 0.06 5918 Federal Register / Vol. 83, No. 29 / Monday, February 12, 2018 / Rules and Regulations Unit SO2 emission limit (lb/MMBtu) Entergy White Bluff Unit 2 .... 0.06 (7) Compliance dates for AEP Flint Creek Unit 1 and Entergy White Bluff Units 1 and 2. The owner or operator of AEP Flint Creek Unit 1 must comply with the SO2 emission limit listed in paragraph (c)(6) of this section by April 27, 2018. The owner or operator of White Bluff Units 1 and 2 must comply with the SO2 emission limit listed in paragraph (c)(6) of this section by October 27, 2021. (8) Compliance determination and reporting and recordkeeping requirements for AEP Flint Creek Unit 1 and Entergy White Bluff Units 1 and 2. (i) For purposes of determining compliance with the SO2 emission limit listed in paragraph (c)(6) of this section for AEP Flint Creek Unit 1 and with the SO2 emission limits listed in paragraph (c)(6) of this section for White Bluff Units 1 and 2, the emissions for each boiler-operating-day for each unit shall be determined by summing the hourly emissions measured in pounds of SO2. For each unit, heat input for each boileroperating-day shall be determined by adding together all hourly heat inputs, in millions of BTU. Each boileroperating-day of the 30-day rolling average for a unit shall be determined by adding together the pounds of SO2 from that day and the preceding 29 boiler-operating-days and dividing the total pounds of SO2 by the sum of the heat input during the same 30 boileroperating-day period. The result shall be the 30 boiler-operating-day rolling average in terms of lb/MMBtu emissions of SO2. If a valid SO2 pounds per hour or heat input is not available for any hour for a unit, that heat input and SO2 pounds per hour shall not be used in the calculation of the 30 boiler-operatingday rolling average for SO2. For each day, records of the total SO2 emitted that day by each emission unit and the sum of the hourly heat inputs for that day must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Records of the 30 boiler-operating-day rolling average for SO2 for each unit as described in this paragraph (c)(8)(i) must be maintained by the owner or operator for each boileroperating-day and made available upon request to EPA and ADEQ representatives. (ii) The owner or operator shall continue to maintain and operate a CEMS for SO2 on the units listed in paragraph (c)(6) of this section in accordance with 40 CFR 60.8 and 60.13(e), (f), and (h), and appendix B of 40 CFR part 60. The owner or operator shall comply with the quality assurance procedures for CEMS found in 40 CFR part 75. Compliance with the emission limits for SO2 shall be determined by using data from a CEMS. (iii) Continuous emissions monitoring shall apply during all periods of operation of the units listed in paragraph (c)(6) of this section, including periods of startup, shutdown, and malfunction, except for CEMS breakdowns, repairs, calibration checks, and zero and span adjustments. Continuous monitoring systems for measuring SO2 and diluent gas shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15minute period. Hourly averages shall be computed using at least one data point in each fifteen-minute quadrant of an hour. Notwithstanding this requirement, an hourly average may be computed from at least two data points separated by a minimum of 15 minutes (where the unit operates for more than one quadrant in an hour) if data are unavailable as a result of performance of calibration, quality assurance, preventive maintenance activities, or backups of data from data acquisition and handling system, and recertification events. When valid SO2 pounds per hour emission data are not obtained because of continuous monitoring system breakdowns, repairs, calibration checks, or zero and span adjustments, emission data must be obtained by using other monitoring systems approved by the EPA to provide emission data for a minimum of 18 hours in each 24-hour period and at least 22 out of 30 successive boiler operating days. (9) Emissions limitations for Entergy White Bluff Auxiliary Boiler. The individual SO2 and PM emission limits for the unit are as listed in the table in this paragraph (c)(9) in pounds per hour (lb/hr). SO2 emission limit (lb/hr) PM emission limit (lb/hr) Entergy White Bluff Auxiliary Boiler ................................................................................................. daltland on DSKBBV9HB2PROD with RULES Unit 105.2 4.5 (10) Compliance dates for Entergy White Bluff Auxiliary Boiler. The owner or operator of the unit must comply with the SO2 and PM emission limits listed in paragraph (c)(9) of this section by October 27, 2016. * * * * * (12) Emissions limitations for Entergy Lake Catherine Unit 4. The unit must not burn fuel oil until BART determinations are promulgated for the unit for SO2 and PM for the fuel oil firing scenario through a FIP and/or through EPA action upon and approval of revised BART determinations submitted by the State as a SIP revision. * * * * * (14) Compliance dates for Domtar Ashdown Mill Power Boiler No. 1. The owner or operator of the boiler must comply with the SO2 and NOX emission VerDate Sep<11>2014 18:49 Feb 09, 2018 Jkt 244001 limits listed in paragraph (c)(13) of this section by November 28, 2016. (15) Compliance determination and reporting and recordkeeping requirements for Domtar Ashdown Paper Mill Power Boiler No. 1. (i)(A) SO2 emissions resulting from combustion of fuel oil shall be determined by assuming that the SO2 content of the fuel delivered to the fuel inlet of the combustion chamber is equal to the SO2 being emitted at the stack. The owner or operator must maintain records of the sulfur content by weight of each fuel oil shipment, where a ‘‘shipment’’ is considered delivery of the entire amount of each order of fuel purchased. Fuel sampling and analysis may be performed by the owner or operator, an outside laboratory, or a fuel supplier. All records pertaining to the sampling of PO 00000 Frm 00048 Fmt 4700 Sfmt 4700 each shipment of fuel oil, including the results of the sulfur content analysis, must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. SO2 emissions resulting from combustion of bark shall be determined by using the following sitespecific curve equation, which accounts for the SO2 scrubbing capabilities of bark combustion: Y= 0.4005 * X ¥ 0.2645 Where: Y = pounds of sulfur emitted per ton of dry fuel feed to the boiler. X = pounds of sulfur input per ton of dry bark. (B) The owner or operator must confirm the site-specific curve equation through stack testing. By October 27, 2017, the owner or operator must E:\FR\FM\12FER1.SGM 12FER1 daltland on DSKBBV9HB2PROD with RULES Federal Register / Vol. 83, No. 29 / Monday, February 12, 2018 / Rules and Regulations provide a report to EPA showing confirmation of the site-specific curve equation accuracy. Records of the quantity of fuel input to the boiler for each fuel type for each day must be compiled no later than 15 days after the end of the month and must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Each boileroperating-day of the 30-day rolling average for the boiler must be determined by adding together the pounds of SO2 from that boileroperating-day and the preceding 29 boiler-operating-days and dividing the total pounds of SO2 by the sum of the total number of boiler operating days (i.e., 30). The result shall be the 30 boiler-operating-day rolling average in terms of lb/day emissions of SO2. Records of the total SO2 emitted for each day must be compiled no later than 15 days after the end of the month and must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Records of the 30 boiler-operating-day rolling averages for SO2 as described in this paragraph (c)(15)(i) must be maintained by the owner or operator for each boileroperating-day and made available upon request to EPA and ADEQ representatives. (ii) If the air permit is revised such that Power Boiler No. 1 is permitted to burn only pipeline quality natural gas, this is sufficient to demonstrate that the boiler is complying with the SO2 emission limit under paragraph (c)(13) of this section. The compliance determination requirements and the reporting and recordkeeping requirements under paragraph (c)(15)(i) of this section would not apply and confirmation of the accuracy of the sitespecific curve equation under paragraph (c)(15)(i)(B) of this section through stack testing would not be required so long as Power Boiler No. 1 is only permitted to burn pipeline quality natural gas. (iii) To demonstrate compliance with the NOX emission limit under paragraph (c)(13) of this section, the owner or operator shall conduct stack testing using EPA Reference Method 7E, found at 40 CFR part 60, appendix A, once every 5 years, beginning October 27, 2017. Records and reports pertaining to the stack testing must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. (iv) If the air permit is revised such that Power Boiler No. 1 is permitted to burn only pipeline quality natural gas, the owner or operator may demonstrate compliance with the NOX emission VerDate Sep<11>2014 18:49 Feb 09, 2018 Jkt 244001 limit under paragraph (c)(13) of this section by calculating NOX emissions using fuel usage records and the applicable NOX emission factor under AP–42, Compilation of Air Pollutant Emission Factors, section 1.4, Table 1.4– 1. Records of the quantity of natural gas input to the boiler for each day must be compiled no later than 15 days after the end of the month and must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Records of the calculation of NOX emissions for each day must be compiled no later than 15 days after the end of the month and must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Each boiler-operatingday of the 30-day rolling average for the boiler must be determined by adding together the pounds of NOX from that day and the preceding 29 boileroperating-days and dividing the total pounds of NOX by the sum of the total number of hours during the same 30 boiler-operating-day period. The result shall be the 30 boiler-operating-day rolling average in terms of lb/hr emissions of NOX. Records of the 30 boiler-operating-day rolling average for NOX must be maintained by the owner or operator for each boiler-operating-day and made available upon request to EPA and ADEQ representatives. Under these circumstances, the compliance determination requirements and the reporting and recordkeeping requirements under paragraph (c)(15)(iii) of this section would not apply. * * * * * (17) SO2 and NOX Compliance dates for Domtar Ashdown Mill Power Boiler No. 2. The owner or operator of the boiler must comply with the SO2 and NOX emission limits listed in paragraph (c)(16) of this section by October 27, 2021. (18) SO2 and NOX Compliance determination and reporting and recordkeeping requirements for Domtar Ashdown Mill Power Boiler No. 2. (i) NOX and SO2 emissions for each day shall be determined by summing the hourly emissions measured in pounds of NOX or pounds of SO2. Each boileroperating-day of the 30-day rolling average for the boiler shall be determined by adding together the pounds of NOX or SO2 from that day and the preceding 29 boiler-operatingdays and dividing the total pounds of NOX or SO2 by the sum of the total number of hours during the same 30 boiler-operating-day period. The result shall be the 30 boiler-operating-day PO 00000 Frm 00049 Fmt 4700 Sfmt 4700 5919 rolling average in terms of lb/hr emissions of NOX or SO2. If a valid NOX pounds per hour or SO2 pounds per hour is not available for any hour for the boiler, that NOX pounds per hour shall not be used in the calculation of the 30 boiler-operating-day rolling average for NOX. For each day, records of the total SO2 and NOX emitted for that day by the boiler must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Records of the 30 boiler-operating-day rolling average for SO2 and NOX for the boiler as described in this paragraph (c)(18)(i) must be maintained by the owner or operator for each boiler-operating-day and made available upon request to EPA and ADEQ representatives. (ii) The owner or operator shall continue to maintain and operate a CEMS for SO2 and NOX on the boiler listed in paragraph (c)(16) of this section in accordance with 40 CFR 60.8 and 60.13(e), (f), and (h), and appendix B of 40 CFR part 60. The owner or operator shall comply with the quality assurance procedures for CEMS found in 40 CFR part 60. Compliance with the emission limits for SO2 and NOX shall be determined by using data from a CEMS. (iii) Continuous emissions monitoring shall apply during all periods of operation of the boiler listed in paragraph (c)(16) of this section, including periods of startup, shutdown, and malfunction, except for CEMS breakdowns, repairs, calibration checks, and zero and span adjustments. Continuous monitoring systems for measuring SO2 and NOX and diluent gas shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15minute period. Hourly averages shall be computed using at least one data point in each fifteen-minute quadrant of an hour. Notwithstanding this requirement, an hourly average may be computed from at least two data points separated by a minimum of 15 minutes (where the unit operates for more than one quadrant in an hour) if data are unavailable as a result of performance of calibration, quality assurance, preventive maintenance activities, or backups of data from data acquisition and handling system, and recertification events. When valid SO2 or NOX pounds per hour emission data are not obtained because of continuous monitoring system breakdowns, repairs, calibration checks, or zero and span adjustments, emission data must be obtained by using other monitoring systems approved by the EPA to provide emission data for a minimum of 18 hours in each 24-hour E:\FR\FM\12FER1.SGM 12FER1 daltland on DSKBBV9HB2PROD with RULES 5920 Federal Register / Vol. 83, No. 29 / Monday, February 12, 2018 / Rules and Regulations period and at least 22 out of 30 successive boiler operating days. (iv) If the air permit is revised such that Power Boiler No. 2 is permitted to burn only pipeline quality natural gas, this is sufficient to demonstrate that the boiler is complying with the SO2 emission limit under paragraph (c)(16) of this section. Under these circumstances, the compliance determination requirements under paragraphs (c)(18)(i) through (iii) of this section would not apply to the SO2 emission limit listed in paragraph (c)(16) of this section. (v) If the air permit is revised such that Power Boiler No. 2 is permitted to burn only pipeline quality natural gas and the operation of the CEMS is not required under other applicable requirements, the owner or operator may demonstrate compliance with the NOX emission limit under paragraph (c)(16) of this section by calculating NOX emissions using fuel usage records and the applicable NOX emission factor under AP–42, Compilation of Air Pollutant Emission Factors, section 1.4, Table 1.4–1. Records of the quantity of natural gas input to the boiler for each day must be compiled no later than 15 days after the end of the month and must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Records of the calculation of NOX emissions for each day must be compiled no later than 15 days after the end of the month and must be maintained and made available upon request to EPA and ADEQ representatives. Each boiler-operatingday of the 30-day rolling average for the boiler must be determined by adding together the pounds of NOX from that day and the preceding 29 boileroperating-days and dividing the total pounds of NOX by the sum of the total number of hours during the same 30 boiler-operating-day period. The result shall be the 30 boiler-operating-day rolling average in terms of lb/hr emissions of NOX. Records of the 30 boiler-operating-day rolling average for NOX must be maintained by the owner or operator for each boiler-operating-day and made available upon request to EPA and ADEQ representatives. Under these circumstances, the compliance determination requirements under paragraphs (c)(18)(i) through (iii) of this section would not apply to the NOX emission limit. * * * * * (20) PM compliance dates for Domtar Ashdown Mill Power Boiler No. 2. The owner or operator of the boiler must VerDate Sep<11>2014 18:49 Feb 09, 2018 Jkt 244001 comply with the PM BART requirement listed in paragraph (c)(19) of this section by November 28, 2016. (21) Alternative PM Compliance Determination for Domtar Ashdown Paper Mill Power Boiler No.2. If the air permit is revised such that Power Boiler No. 2 is permitted to burn only pipeline quality natural gas, this is sufficient to demonstrate that the boiler is complying with the PM BART requirement under paragraph (c)(19) of this section. (22) Emissions limitations for Entergy Independence Units 1 and 2. The individual emission limits for each unit are as listed in the table in this paragraph (c)(22) in pounds per million British thermal units (lb/MMBtu). The SO2 emission limits listed in the table as lb/MMBtu are on a rolling 30 boileroperating-day averaging period. SO2 Emission limit (lb/MMBtu) Unit Entergy Independence Unit 1 Entergy Independence Unit 2 0.06 0.06 (23) Compliance dates for Entergy Independence Units 1 and 2. The owner or operator of each unit must comply with the SO2 emission limits in paragraph (c)(22) of this section by October 27, 2021. (24) Compliance determination and reporting and recordkeeping requirements for Entergy Independence Units 1 and 2. (i) For purposes of determining compliance with the SO2 emissions limit listed in paragraph (c)(22) of this section for each unit, the SO2 emissions for each boiler-operatingday shall be determined by summing the hourly emissions measured in pounds of SO2. For each unit, heat input for each boiler-operating-day shall be determined by adding together all hourly heat inputs, in millions of BTU. Each boiler-operating-day of the thirtyday rolling average for a unit shall be determined by adding together the pounds of SO2 from that day and the preceding 29 boiler-operating-days and dividing the total pounds of SO2 by the sum of the heat input during the same 30 boiler-operating-day period. The result shall be the 30 boiler-operatingday rolling average in terms of lb/ MMBtu emissions of SO2. If a valid SO2 pounds per hour or heat input is not available for any hour for a unit, that heat input and SO2 pounds per hour shall not be used in the calculation of the applicable 30 boiler-operating-days rolling average. For each day, records of the total SO2 emitted that day by each PO 00000 Frm 00050 Fmt 4700 Sfmt 4700 emission unit and the sum of the hourly heat inputs for that day must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Records of the 30 boiler-operating-day rolling average for each unit as described in this paragraph (c)(24)(i) must be maintained by the owner or operator for each boiler-operating-day and made available upon request to EPA and ADEQ representatives. (ii) The owner or operator shall continue to maintain and operate a CEMS for SO2 on the units listed in paragraph (c)(22) in accordance with 40 CFR 60.8 and 60.13(e), (f), and (h), and appendix B of 40 CFR part 60. The owner or operator shall comply with the quality assurance procedures for CEMS found in 40 CFR part 75. Compliance with the emission limits for SO2 shall be determined by using data from a CEMS. (iii) Continuous emissions monitoring shall apply during all periods of operation of the units listed in paragraph (c)(22) of this section, including periods of startup, shutdown, and malfunction, except for CEMS breakdowns, repairs, calibration checks, and zero and span adjustments. Continuous monitoring systems for measuring SO2 and diluent gas shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15minute period. Hourly averages shall be computed using at least one data point in each fifteen-minute quadrant of an hour. Notwithstanding this requirement, an hourly average may be computed from at least two data points separated by a minimum of 15 minutes (where the unit operates for more than one quadrant in an hour) if data are unavailable as a result of performance of calibration, quality assurance, preventive maintenance activities, or backups of data from data acquisition and handling system, and recertification events. When valid SO2 pounds per hour emission data are not obtained because of continuous monitoring system breakdowns, repairs, calibration checks, or zero and span adjustments, emission data must be obtained by using other monitoring systems approved by the EPA to provide emission data for a minimum of 18 hours in each 24-hour period and at least 22 out of 30 successive boiler operating days. * * * * * [FR Doc. 2018–02145 Filed 2–9–18; 8:45 am] BILLING CODE 6560–50–P E:\FR\FM\12FER1.SGM 12FER1

Agencies

[Federal Register Volume 83, Number 29 (Monday, February 12, 2018)]
[Rules and Regulations]
[Pages 5915-5920]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2018-02145]


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ENVIRONMENTAL PROTECTION AGENCY

40 CFR Part 52

[EPA-R06-OAR-2015-0189; FRL-9973-61-OAR]


Approval and Promulgation of Air Quality Implementation Plans; 
State of Arkansas; Regional Haze and Interstate Visibility Transport 
Federal Implementation Plan Revisions; Withdrawal of Federal 
Implementation Plan for NOX for Electric Generating Units in Arkansas

AGENCY: Environmental Protection Agency (EPA).

ACTION: Final rule.

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SUMMARY: The Environmental Protection Agency (EPA) is amending a 
Federal Implementation Plan (FIP) that addresses regional haze for the 
first planning period for Arkansas that was published in the Federal 
Register on September 27, 2016, as it applies to the nitrogen oxide 
(NOX) requirements for the Arkansas Electric Cooperative 
Corporation (AECC) Bailey Plant Unit 1; AECC McClellan Plant Unit 1; 
the American Electric Power/Southwestern Electric Power Company (AEP/
SWEPCO) Flint Creek Plant Boiler No. 1; Entergy Arkansas, Inc. 
(Entergy) Lake Catherine Plant Unit 4; Entergy White Bluff Plant Units 
1 and 2 and the Auxiliary Boiler; and Entergy Independence Plant Units 
1 and 2. We are removing these FIP requirements because in a separate 
action being published in this Federal Register, we are taking final 
action to approve revisions to the Arkansas State Implementation Plan 
(SIP) submitted by the State of Arkansas through the Arkansas 
Department of Environmental Quality (ADEQ) on October 31, 2017, that 
address NOX requirements for the nine aforementioned units.

DATES: This final rule will be effective March 14, 2018.

ADDRESSES: The EPA has established a docket for this action under 
Docket No. EPA-R06-OAR-2015-0189. All documents in the dockets are 
listed on the https://www.regulations.gov website. Although listed in 
the index, some information is not publicly available, e.g., 
Confidential Business Information or other information whose disclosure 
is restricted by statute. Certain other material, such as copyrighted 
material, is not placed on the internet and will be publicly available 
only in hard copy form. Publicly available docket materials are 
available either electronically through https://www.regulations.gov or 
in hard copy at the EPA Region 6, 1445 Ross Avenue, Suite 700, Dallas, 
Texas 75202-2733.

FOR FURTHER INFORMATION CONTACT: Dayana Medina, (214) 665-7241; 
[email protected].

SUPPLEMENTARY INFORMATION: Throughout this document wherever ``we,'' 
``us,'' or ``our'' is used, we mean the EPA.

Table of Contents

I. What is the background for this action?
II. What final action is EPA taking?
III. Responses to Comments Received
IV. Statutory and Executive Order Reviews

I. What is the background for this action?

    Arkansas submitted a SIP revision on September 9, 2008, to address 
the first regional haze implementation period. On August 3, 2010, 
Arkansas submitted a SIP revision with non-substantive revisions to the 
Arkansas Pollution Control and Ecology Commission (APCEC) Regulation 
19, Chapter 15; this Chapter identified the BART-eligible and subject-
to-BART sources in Arkansas and established the BART emission limits 
for subject-to-BART sources. On September 27, 2011, the State submitted 
supplemental information to address the regional haze requirements. We 
are hereafter referring to these regional haze submittals collectively 
as the ``2008 Arkansas Regional Haze SIP.'' On March 12, 2012, we 
partially approved and partially disapproved the 2008 Arkansas Regional 
Haze SIP.\1\ On September 27, 2016, we published a FIP (the Arkansas 
Regional Haze FIP) addressing the disapproved portions of the 2008 
Arkansas Regional Haze SIP.\2\ Among other things, the FIP established 
NOX emission limits under the BART requirements for Bailey 
Unit 1; McClellan Unit 1; Flint Creek Boiler No. 1; Lake Catherine Unit 
4; and White Bluff Units 1 and 2 and the Auxiliary Boiler. The FIP also 
established NOX emission limits under the reasonable 
progress requirements for Independence Units 1 and 2.
---------------------------------------------------------------------------

    \1\ 77 FR 14604.
    \2\ 81 FR 66332; see also 81 FR 68319 (October 4, 2016) 
(correction).
---------------------------------------------------------------------------

    In response to petitions submitted by the State of Arkansas and 
industry parties seeking reconsideration and an administrative stay of 
the final Arkansas Regional Haze FIP,\3\ in a letter dated April 14, 
2017, we announced the convening of a proceeding to reconsider several 
elements of the FIP, including the appropriate compliance dates for the 
NOX emission limits for Flint Creek Unit 1, White Bluff 
Units 1 and 2, and Independence Units 1 and 2.\4\ EPA also published a 
document in the Federal Register on April 25, 2017, administratively 
staying the effectiveness of the 18-month NOX compliance 
dates in the FIP for these units for a period of 90 days.\5\ On July 
13, 2017, the EPA published a proposed rule that would extend the FIP's 
NOX compliance dates for Flint Creek Unit 1, White Bluff 
Units 1 and 2, and Independence Units 1 and 2, by 21 months to January 
27, 2020.6 7
---------------------------------------------------------------------------

    \3\ See the docket associated with this proposed rulemaking for 
a copy of the petitions for reconsideration and administrative stay 
submitted by the State of Arkansas; Entergy Arkansas Inc., Entergy 
Mississippi Inc., and Entergy Power LLC (collectively ``Entergy''); 
AECC; and the Energy and Environmental Alliance of Arkansas (EEAA).
    \4\ Letter from E. Scott Pruitt, Administrator, EPA, to Nicholas 
Jacob Bronni & Jamie Leigh Ewing, Arkansas Attorney General's 
Office, (April 14, 2017). A copy of this letter is included in the 
docket, https://www.regulations.gov/document?D=EPA-R06-OAR-2015-0189-0240.
    \5\ 82 FR 18994.
    \6\ 82 FR 32284.
    \7\ EPA has not finalized the July 13, 2017 proposed rule. The 
separate final action approving the Arkansas Regional Haze 
NOX SIP revision together with this final action EPA is 
taking to withdraw the source-specific NOX emission 
limits for the nine EGUs in the Arkansas Regional Haze FIP, make it 
unnecessary to finalize our July 13, 2017 proposed rule to revise 
the NOX compliance dates in the Arkansas Regional Haze 
FIP.
---------------------------------------------------------------------------

    On July 12, 2017, Arkansas submitted a proposed SIP revision with a 
request for parallel processing, addressing the NOX 
requirements for Bailey Unit 1, McClellan Unit 1, Flint Creek Boiler 
No. 1, Lake Catherine Unit 4, White Bluff Units 1 and 2 and the 
Auxiliary Boiler, and Independence Units 1 and 2 (Arkansas Regional 
Haze NOX SIP

[[Page 5916]]

revision or Arkansas NOX SIP revision). Arkansas' proposed 
July 2017 Regional Haze NOX SIP revision addressed the 
NOX BART requirements for Arkansas' EGUs by relying on 
participation in the Cross State Air Pollution Rule (CSAPR) ozone 
season NOX trading program as an alternative to BART. The 
July 2017 Regional Haze NOX SIP revision proposal also made 
the determination that no additional NOX emission controls 
for Arkansas sources, beyond participation in CSAPR's ozone season 
NOX trading program, are required for achieving reasonable 
progress in Arkansas. The July 2017 Regional Haze SIP revision 
addresses NOX requirements for the same EGUs for which we 
established source-specific NOX emission limits in the 
September 27, 2016 FIP. In a document published in the Federal Register 
on September 11, 2017, we proposed to approve the Arkansas Regional 
Haze NOX SIP revision and proposed to withdraw corresponding 
parts of the FIP.\8\ On October 31, 2017, we received ADEQ's final 
NOX SIP revision addressing BART and reasonable progress 
requirements for NOX for EGUs in Arkansas for the first 
implementation period. In a final action being published separately in 
this Federal Register, we are taking final action to approve the 
Arkansas Regional Haze NOX SIP revision.
---------------------------------------------------------------------------

    \8\ 82 FR 42627.
---------------------------------------------------------------------------

    The background for this final rule and the separate action also 
being published in this Federal Register that approves the Arkansas 
Regional Haze NOX SIP revision is also discussed in detail 
in our September 11, 2017 proposal.\9\ The comment period was open for 
30 days, and we received comments from three commenters in response to 
our proposed action.
---------------------------------------------------------------------------

    \9\ 82 FR 42627.
---------------------------------------------------------------------------

II. What final action is EPA taking?

    We are withdrawing those portions of the Arkansas Regional Haze FIP 
at 40 CFR 52.173 that impose NOX requirements on Bailey Unit 
1; McClellan Unit 1; Flint Creek Boiler No. 1; Lake Catherine Unit 4; 
White Bluff Units 1 and 2 and the Auxiliary Boiler; and Independence 
Units 1 and 2. Therefore, as of the effective date of this final rule, 
the Arkansas Regional Haze FIP NOX requirements will no 
longer apply to the nine aforementioned units. All other provisions of 
the Arkansas Regional Haze FIP are unaffected by this action and remain 
in place.
    As explained in our September 11, 2017 proposal,\10\ this action is 
made possible because of our separate action being published in this 
Federal Register to approve the Arkansas Regional Haze NOX 
SIP revision submitted to us on July 12, 2017, with a request for 
parallel processing. On October 31, 2017, we received ADEQ's final SIP 
revision addressing NOX BART for EGUs in Arkansas and the 
reasonable progress requirements for NOX for the first 
implementation period. The final Arkansas Regional Haze NOX 
SIP revision we received on October 31, 2017, did not contain 
significant changes from the state's proposed SIP revision. Therefore, 
it is appropriate for us to take final action, as proposed, on the 
final SIP revision.
---------------------------------------------------------------------------

    \10\ 82 FR 42627.
---------------------------------------------------------------------------

    EPA has made the determination that the Arkansas Regional Haze NOx 
SIP revision is approvable because the plan's provisions meet all 
applicable requirements of the CAA and EPA implementing regulations. 
EPA is finalizing this action under section 110 and part C of the Act.

III. Responses to Comments Received

    We received a total of three comment letters concerning our 
proposed action. The issues raised in those comment letters are 
summarized, along with our response to each, in the separate document 
being published in this Federal Register that approves the Arkansas 
Regional Haze NOX SIP revision. Copies of the comments are 
available in the docket for this rulemaking.\11\
---------------------------------------------------------------------------

    \11\ Please see Docket No. EPA-R06-OAR-2015-0189 in the 
regulations.gov website.
---------------------------------------------------------------------------

V. Statutory and Executive Order Reviews

    Additional information about these statutes and Executive Orders 
can be found at https://www2.epa.gov/lawsregulations/laws-and-executive-orders.

A. Executive Order 12866: Regulatory Planning and Review and Executive 
Order 13563: Improving Regulation and Regulatory Review

    This action is not a significant regulatory action and was 
therefore not submitted to the Office of Management and Budget (OMB) 
for review. This final rule revises a FIP to withdraw source-specific 
NOX emission limits for only six facilities in Arkansas and 
is therefore not a rule of general applicability.

B. Executive Order 13771: Reducing Regulations and Controlling 
Regulatory Costs

    This action is not an Executive Order 13771 regulatory action 
because this action is not significant under Executive Order 12866.

C. Paperwork Reduction Act (PRA)

    This action does not impose an information collection burden under 
the provisions of the PRA. Burden is defined at 5 CFR 1320.3(b). This 
final rule revises a FIP to withdraw source-specific NOX 
emission limits for six facilities in Arkansas.

D. Regulatory Flexibility Act (RFA)

    I certify that this final action will not have a significant 
economic impact on a substantial number of small entities under the 
RFA. This final action will not impose any requirements on small 
entities. This final action revises a FIP to withdraw source-specific 
NOX emission limits that apply to six power plants in 
Arkansas.

E. Unfunded Mandates Reform Act (UMRA)

    This action does not contain any unfunded mandate as described in 
UMRA, 2 U.S.C. 1531-1538, and does not significantly or uniquely affect 
small governments. This action does not impose additional requirements 
beyond those imposed by state law. Accordingly, no additional costs to 
State, local, or tribal governments, or to the private sector, will 
result from this action.

F. Executive Order 13132: Federalism

    This action does not have federalism implications. It will not have 
substantial direct effects on the states, on the relationship between 
the national government and the states, or on the distribution of power 
and responsibilities among the various levels of government.

G. Executive Order 13175: Consultation and Coordination With Indian 
Tribal Governments

    This action does not have tribal implications, as specified in 
Executive Order 13175, because this partial FIP withdrawal does not 
apply on any Indian reservation land or in any other area where the EPA 
or an Indian tribe has demonstrated that a tribe has jurisdiction, and 
will not impose substantial direct costs on tribal governments or 
preempt tribal law. This final action revises a FIP to withdraw source-
specific NOX emission limits that apply to six power plants 
in Arkansas. There are no Indian reservation lands in Arkansas. Thus, 
Executive Order 13175 does not apply to this action.

[[Page 5917]]

H. Executive Order 13045: Protection of Children From Environmental 
Health Risks and Safety Risks

    The EPA interprets Executive Order 13045 as applying only to those 
regulatory actions that concern environmental health or safety risks 
that the EPA has reason to believe may disproportionately affect 
children, per the definition of ``covered regulatory action'' in 
section 2-202 of the Executive Order. This action is not subject to 
Executive Order 13045 because it does not concern an environmental 
health risk or safety risk.

I. Executive Order 13211: Actions That Significantly Affect Energy 
Supply, Distribution, or Use

    This action is not subject to Executive Order 13211, because it is 
not a significant regulatory action under Executive Order 12866.

J. National Technology Transfer and Advancement Act (NTTAA)

    This rulemaking does not involve technical standards.

K. Executive Order 12898: Federal Actions To Address Environmental 
Justice in Minority Populations and Low-Income Populations

    The EPA believes the human health or environmental risk addressed 
by this action will not have potentially disproportionately high and 
adverse human health or environmental effects on minority, low-income 
or indigenous populations.

L. Determination Under Section 307(d)

    Pursuant to CAA section 307(d)(1)(B), this action is subject to the 
requirements of CAA section 307(d), as it revises a FIP under CAA 
section 110(c).

M. Congressional Review Act (CRA)

    This rule is exempt from the CRA because it is a rule of particular 
applicably. EPA is not required to submit a rule report regarding this 
action under section 801 because this is a rule of particular 
applicability that only affects six facilities in Arkansas.

N. Petitions for Judicial Review

    Under section 307(b)(1) of the Clean Air Act, petitions for 
judicial review of this action must be filed in the United States Court 
of Appeals for the appropriate circuit by April 13, 2018. Filing a 
petition for reconsideration by the Administrator of this final rule 
does not affect the finality of this rule for the purposes of judicial 
review nor does it extend the time within which a petition for judicial 
review may be filed, and shall not postpone the effectiveness of such 
rule or action. This action may not be challenged later in proceedings 
to enforce its requirements (see section 307(b)(2)).

List of Subjects in 40 CFR Part 52

    Air pollution control, Best available retrofit technology, 
Environmental protection, Incorporation by reference, Intergovernmental 
relations, Nitrogen dioxide, Ozone, Regional haze, Reporting and 
recordkeeping requirements, Visibility.

    Dated: January 25, 2018.
E. Scott Pruitt,
Administrator.

    Title 40, chapter I, of the Code of Federal Regulations is amended 
as follows:

PART 52--APPROVAL AND PROMULGATION OF IMPLEMENTATION PLANS

0
1. The authority citation for part 52 continues to read as follows:

    Authority: 42 U.S.C. 7401 et seq.

Subpart E--Arkansas

0
2. Section 52.173 is amended by:
0
a. Revising paragraphs (c)(3) through (10) and (12);
0
b. Removing paragraphs (c)(13) and (14);
0
c. Redesignating paragraphs (c)(15) through (29) as paragraphs (c)(13) 
through (27); and
0
d. Revising newly redesignated paragraphs (c)(14), (15), (17), (18), 
and (20) through (24).
    The revisions read as follows:


Sec.  52.173  Visibility protection.

* * * * *
    (c) * * *
    (3) Emissions limitations for AECC Bailey Unit 1 and AECC McClellan 
Unit 1. The individual SO2 and PM emission limits for each 
unit are as listed in the table in this paragraph (c)(3).

----------------------------------------------------------------------------------------------------------------
                      Unit                              SO2 emission limit               PM emission limit
----------------------------------------------------------------------------------------------------------------
AECC Bailey Unit 1..............................  Use of fuel with a sulfur       Use of fuel with a sulfur
                                                   content limit of 0.5% by        content limit of 0.5% by
                                                   weight.                         weight.
AECC McClellan Unit 1...........................  Use of fuel with a sulfur       Use of fuel with a sulfur
                                                   content limit of 0.5% by        content limit of 0.5% by
                                                   weight.                         weight.
----------------------------------------------------------------------------------------------------------------

    (4) Compliance dates for AECC Bailey Unit 1 and AECC McClellan Unit 
1. The owner or operator of each unit must comply with the 
SO2 and PM requirements listed in paragraph (c)(3) of this 
section by October 27, 2021. As of October 27, 2016, the owner or 
operator of each unit shall not purchase fuel for combustion at the 
unit that does not meet the sulfur content limit in paragraph (c)(3) of 
this section. The owner or operator of each unit must comply with the 
requirement in paragraph (c)(3) of this section to burn only fuel with 
a sulfur content limit of 0.5% by weight by October 27, 2021.
    (5) Compliance determination and reporting and recordkeeping 
requirements for AECC Bailey Unit 1 and AECC McClellan Unit 1 for SO4 
and PM. To determine compliance with the SO2 and PM 
requirements listed in paragraph (c)(3) of this section, the owner or 
operator shall sample and analyze each shipment of fuel to determine 
the sulfur content by weight, except for natural gas shipments. A 
``shipment'' is considered delivery of the entire amount of each order 
of fuel purchased. Fuel sampling and analysis may be performed by the 
owner or operator of an affected unit, an outside laboratory, or a fuel 
supplier. All records pertaining to the sampling of each shipment of 
fuel as described in this paragraph (c)(5), including the results of 
the sulfur content analysis, must be maintained by the owner or 
operator and made available upon request to EPA and ADEQ 
representatives.
    (6) Emissions limitations for AEP Flint Creek Unit 1 and Entergy 
White Bluff Units 1 and 2. The individual SO2 emission 
limits for each unit are as listed in the table in this paragraph 
(c)(6), as specified in pounds per million British thermal units (lb/
MMBtu). The SO2 emission limits of 0.06 lb/MMBtu are on a 
rolling 30 boiler-operating-day averaging period.

------------------------------------------------------------------------
                                                           SO2 emission
                          Unit                              limit (lb/
                                                              MMBtu)
------------------------------------------------------------------------
AEP Flint Creek Unit 1..................................            0.06
Entergy White Bluff Unit 1..............................            0.06

[[Page 5918]]

 
Entergy White Bluff Unit 2..............................            0.06
------------------------------------------------------------------------

    (7) Compliance dates for AEP Flint Creek Unit 1 and Entergy White 
Bluff Units 1 and 2. The owner or operator of AEP Flint Creek Unit 1 
must comply with the SO2 emission limit listed in paragraph 
(c)(6) of this section by April 27, 2018. The owner or operator of 
White Bluff Units 1 and 2 must comply with the SO2 emission 
limit listed in paragraph (c)(6) of this section by October 27, 2021.
    (8) Compliance determination and reporting and recordkeeping 
requirements for AEP Flint Creek Unit 1 and Entergy White Bluff Units 1 
and 2. (i) For purposes of determining compliance with the 
SO2 emission limit listed in paragraph (c)(6) of this 
section for AEP Flint Creek Unit 1 and with the SO2 emission 
limits listed in paragraph (c)(6) of this section for White Bluff Units 
1 and 2, the emissions for each boiler-operating-day for each unit 
shall be determined by summing the hourly emissions measured in pounds 
of SO2. For each unit, heat input for each boiler-operating-
day shall be determined by adding together all hourly heat inputs, in 
millions of BTU. Each boiler-operating-day of the 30-day rolling 
average for a unit shall be determined by adding together the pounds of 
SO2 from that day and the preceding 29 boiler-operating-days 
and dividing the total pounds of SO2 by the sum of the heat 
input during the same 30 boiler-operating-day period. The result shall 
be the 30 boiler-operating-day rolling average in terms of lb/MMBtu 
emissions of SO2. If a valid SO2 pounds per hour 
or heat input is not available for any hour for a unit, that heat input 
and SO2 pounds per hour shall not be used in the calculation 
of the 30 boiler-operating-day rolling average for SO2. For 
each day, records of the total SO2 emitted that day by each 
emission unit and the sum of the hourly heat inputs for that day must 
be maintained by the owner or operator and made available upon request 
to EPA and ADEQ representatives. Records of the 30 boiler-operating-day 
rolling average for SO2 for each unit as described in this 
paragraph (c)(8)(i) must be maintained by the owner or operator for 
each boiler-operating-day and made available upon request to EPA and 
ADEQ representatives.
    (ii) The owner or operator shall continue to maintain and operate a 
CEMS for SO2 on the units listed in paragraph (c)(6) of this 
section in accordance with 40 CFR 60.8 and 60.13(e), (f), and (h), and 
appendix B of 40 CFR part 60. The owner or operator shall comply with 
the quality assurance procedures for CEMS found in 40 CFR part 75. 
Compliance with the emission limits for SO2 shall be 
determined by using data from a CEMS.
    (iii) Continuous emissions monitoring shall apply during all 
periods of operation of the units listed in paragraph (c)(6) of this 
section, including periods of startup, shutdown, and malfunction, 
except for CEMS breakdowns, repairs, calibration checks, and zero and 
span adjustments. Continuous monitoring systems for measuring 
SO2 and diluent gas shall complete a minimum of one cycle of 
operation (sampling, analyzing, and data recording) for each successive 
15-minute period. Hourly averages shall be computed using at least one 
data point in each fifteen-minute quadrant of an hour. Notwithstanding 
this requirement, an hourly average may be computed from at least two 
data points separated by a minimum of 15 minutes (where the unit 
operates for more than one quadrant in an hour) if data are unavailable 
as a result of performance of calibration, quality assurance, 
preventive maintenance activities, or backups of data from data 
acquisition and handling system, and recertification events. When valid 
SO2 pounds per hour emission data are not obtained because 
of continuous monitoring system breakdowns, repairs, calibration 
checks, or zero and span adjustments, emission data must be obtained by 
using other monitoring systems approved by the EPA to provide emission 
data for a minimum of 18 hours in each 24-hour period and at least 22 
out of 30 successive boiler operating days.
    (9) Emissions limitations for Entergy White Bluff Auxiliary Boiler. 
The individual SO2 and PM emission limits for the unit are 
as listed in the table in this paragraph (c)(9) in pounds per hour (lb/
hr).

----------------------------------------------------------------------------------------------------------------
                                                                      SO2 emission limit   PM emission limit (lb/
                               Unit                                        (lb/hr)                  hr)
----------------------------------------------------------------------------------------------------------------
Entergy White Bluff Auxiliary Boiler..............................                 105.2                    4.5
----------------------------------------------------------------------------------------------------------------

    (10) Compliance dates for Entergy White Bluff Auxiliary Boiler. The 
owner or operator of the unit must comply with the SO2 and 
PM emission limits listed in paragraph (c)(9) of this section by 
October 27, 2016.
* * * * *
    (12) Emissions limitations for Entergy Lake Catherine Unit 4. The 
unit must not burn fuel oil until BART determinations are promulgated 
for the unit for SO2 and PM for the fuel oil firing scenario 
through a FIP and/or through EPA action upon and approval of revised 
BART determinations submitted by the State as a SIP revision.
* * * * *
    (14) Compliance dates for Domtar Ashdown Mill Power Boiler No. 1. 
The owner or operator of the boiler must comply with the SO2 
and NOX emission limits listed in paragraph (c)(13) of this 
section by November 28, 2016.
    (15) Compliance determination and reporting and recordkeeping 
requirements for Domtar Ashdown Paper Mill Power Boiler No. 1. (i)(A) 
SO2 emissions resulting from combustion of fuel oil shall be 
determined by assuming that the SO2 content of the fuel 
delivered to the fuel inlet of the combustion chamber is equal to the 
SO2 being emitted at the stack. The owner or operator must 
maintain records of the sulfur content by weight of each fuel oil 
shipment, where a ``shipment'' is considered delivery of the entire 
amount of each order of fuel purchased. Fuel sampling and analysis may 
be performed by the owner or operator, an outside laboratory, or a fuel 
supplier. All records pertaining to the sampling of each shipment of 
fuel oil, including the results of the sulfur content analysis, must be 
maintained by the owner or operator and made available upon request to 
EPA and ADEQ representatives. SO2 emissions resulting from 
combustion of bark shall be determined by using the following site-
specific curve equation, which accounts for the SO2 
scrubbing capabilities of bark combustion:

Y= 0.4005 * X - 0.2645

Where:

Y = pounds of sulfur emitted per ton of dry fuel feed to the boiler.
X = pounds of sulfur input per ton of dry bark.

    (B) The owner or operator must confirm the site-specific curve 
equation through stack testing. By October 27, 2017, the owner or 
operator must

[[Page 5919]]

provide a report to EPA showing confirmation of the site-specific curve 
equation accuracy. Records of the quantity of fuel input to the boiler 
for each fuel type for each day must be compiled no later than 15 days 
after the end of the month and must be maintained by the owner or 
operator and made available upon request to EPA and ADEQ 
representatives. Each boiler-operating-day of the 30-day rolling 
average for the boiler must be determined by adding together the pounds 
of SO2 from that boiler-operating-day and the preceding 29 
boiler-operating-days and dividing the total pounds of SO2 
by the sum of the total number of boiler operating days (i.e., 30). The 
result shall be the 30 boiler-operating-day rolling average in terms of 
lb/day emissions of SO2. Records of the total SO2 
emitted for each day must be compiled no later than 15 days after the 
end of the month and must be maintained by the owner or operator and 
made available upon request to EPA and ADEQ representatives. Records of 
the 30 boiler-operating-day rolling averages for SO2 as 
described in this paragraph (c)(15)(i) must be maintained by the owner 
or operator for each boiler-operating-day and made available upon 
request to EPA and ADEQ representatives.
    (ii) If the air permit is revised such that Power Boiler No. 1 is 
permitted to burn only pipeline quality natural gas, this is sufficient 
to demonstrate that the boiler is complying with the SO2 
emission limit under paragraph (c)(13) of this section. The compliance 
determination requirements and the reporting and recordkeeping 
requirements under paragraph (c)(15)(i) of this section would not apply 
and confirmation of the accuracy of the site-specific curve equation 
under paragraph (c)(15)(i)(B) of this section through stack testing 
would not be required so long as Power Boiler No. 1 is only permitted 
to burn pipeline quality natural gas.
    (iii) To demonstrate compliance with the NOX emission 
limit under paragraph (c)(13) of this section, the owner or operator 
shall conduct stack testing using EPA Reference Method 7E, found at 40 
CFR part 60, appendix A, once every 5 years, beginning October 27, 
2017. Records and reports pertaining to the stack testing must be 
maintained by the owner or operator and made available upon request to 
EPA and ADEQ representatives.
    (iv) If the air permit is revised such that Power Boiler No. 1 is 
permitted to burn only pipeline quality natural gas, the owner or 
operator may demonstrate compliance with the NOX emission 
limit under paragraph (c)(13) of this section by calculating 
NOX emissions using fuel usage records and the applicable 
NOX emission factor under AP-42, Compilation of Air 
Pollutant Emission Factors, section 1.4, Table 1.4-1. Records of the 
quantity of natural gas input to the boiler for each day must be 
compiled no later than 15 days after the end of the month and must be 
maintained by the owner or operator and made available upon request to 
EPA and ADEQ representatives. Records of the calculation of 
NOX emissions for each day must be compiled no later than 15 
days after the end of the month and must be maintained by the owner or 
operator and made available upon request to EPA and ADEQ 
representatives. Each boiler-operating-day of the 30-day rolling 
average for the boiler must be determined by adding together the pounds 
of NOX from that day and the preceding 29 boiler-operating-
days and dividing the total pounds of NOX by the sum of the 
total number of hours during the same 30 boiler-operating-day period. 
The result shall be the 30 boiler-operating-day rolling average in 
terms of lb/hr emissions of NOX. Records of the 30 boiler-
operating-day rolling average for NOX must be maintained by 
the owner or operator for each boiler-operating-day and made available 
upon request to EPA and ADEQ representatives. Under these 
circumstances, the compliance determination requirements and the 
reporting and recordkeeping requirements under paragraph (c)(15)(iii) 
of this section would not apply.
* * * * *
    (17) SO2 and NOX Compliance dates for Domtar Ashdown Mill Power 
Boiler No. 2. The owner or operator of the boiler must comply with the 
SO2 and NOX emission limits listed in paragraph 
(c)(16) of this section by October 27, 2021.
    (18) SO2 and NOX Compliance determination and reporting and 
recordkeeping requirements for Domtar Ashdown Mill Power Boiler No. 2. 
(i) NOX and SO2 emissions for each day shall be 
determined by summing the hourly emissions measured in pounds of 
NOX or pounds of SO2. Each boiler-operating-day 
of the 30-day rolling average for the boiler shall be determined by 
adding together the pounds of NOX or SO2 from 
that day and the preceding 29 boiler-operating-days and dividing the 
total pounds of NOX or SO2 by the sum of the 
total number of hours during the same 30 boiler-operating-day period. 
The result shall be the 30 boiler-operating-day rolling average in 
terms of lb/hr emissions of NOX or SO2. If a 
valid NOX pounds per hour or SO2 pounds per hour 
is not available for any hour for the boiler, that NOX 
pounds per hour shall not be used in the calculation of the 30 boiler-
operating-day rolling average for NOX. For each day, records 
of the total SO2 and NOX emitted for that day by 
the boiler must be maintained by the owner or operator and made 
available upon request to EPA and ADEQ representatives. Records of the 
30 boiler-operating-day rolling average for SO2 and 
NOX for the boiler as described in this paragraph (c)(18)(i) 
must be maintained by the owner or operator for each boiler-operating-
day and made available upon request to EPA and ADEQ representatives.
    (ii) The owner or operator shall continue to maintain and operate a 
CEMS for SO2 and NOX on the boiler listed in 
paragraph (c)(16) of this section in accordance with 40 CFR 60.8 and 
60.13(e), (f), and (h), and appendix B of 40 CFR part 60. The owner or 
operator shall comply with the quality assurance procedures for CEMS 
found in 40 CFR part 60. Compliance with the emission limits for 
SO2 and NOX shall be determined by using data 
from a CEMS.
    (iii) Continuous emissions monitoring shall apply during all 
periods of operation of the boiler listed in paragraph (c)(16) of this 
section, including periods of startup, shutdown, and malfunction, 
except for CEMS breakdowns, repairs, calibration checks, and zero and 
span adjustments. Continuous monitoring systems for measuring 
SO2 and NOX and diluent gas shall complete a 
minimum of one cycle of operation (sampling, analyzing, and data 
recording) for each successive 15-minute period. Hourly averages shall 
be computed using at least one data point in each fifteen-minute 
quadrant of an hour. Notwithstanding this requirement, an hourly 
average may be computed from at least two data points separated by a 
minimum of 15 minutes (where the unit operates for more than one 
quadrant in an hour) if data are unavailable as a result of performance 
of calibration, quality assurance, preventive maintenance activities, 
or backups of data from data acquisition and handling system, and 
recertification events. When valid SO2 or NOX 
pounds per hour emission data are not obtained because of continuous 
monitoring system breakdowns, repairs, calibration checks, or zero and 
span adjustments, emission data must be obtained by using other 
monitoring systems approved by the EPA to provide emission data for a 
minimum of 18 hours in each 24-hour

[[Page 5920]]

period and at least 22 out of 30 successive boiler operating days.
    (iv) If the air permit is revised such that Power Boiler No. 2 is 
permitted to burn only pipeline quality natural gas, this is sufficient 
to demonstrate that the boiler is complying with the SO2 
emission limit under paragraph (c)(16) of this section. Under these 
circumstances, the compliance determination requirements under 
paragraphs (c)(18)(i) through (iii) of this section would not apply to 
the SO2 emission limit listed in paragraph (c)(16) of this 
section.
    (v) If the air permit is revised such that Power Boiler No. 2 is 
permitted to burn only pipeline quality natural gas and the operation 
of the CEMS is not required under other applicable requirements, the 
owner or operator may demonstrate compliance with the NOX 
emission limit under paragraph (c)(16) of this section by calculating 
NOX emissions using fuel usage records and the applicable 
NOX emission factor under AP-42, Compilation of Air 
Pollutant Emission Factors, section 1.4, Table 1.4-1. Records of the 
quantity of natural gas input to the boiler for each day must be 
compiled no later than 15 days after the end of the month and must be 
maintained by the owner or operator and made available upon request to 
EPA and ADEQ representatives. Records of the calculation of 
NOX emissions for each day must be compiled no later than 15 
days after the end of the month and must be maintained and made 
available upon request to EPA and ADEQ representatives. Each boiler-
operating-day of the 30-day rolling average for the boiler must be 
determined by adding together the pounds of NOX from that 
day and the preceding 29 boiler-operating-days and dividing the total 
pounds of NOX by the sum of the total number of hours during 
the same 30 boiler-operating-day period. The result shall be the 30 
boiler-operating-day rolling average in terms of lb/hr emissions of 
NOX. Records of the 30 boiler-operating-day rolling average 
for NOX must be maintained by the owner or operator for each 
boiler-operating-day and made available upon request to EPA and ADEQ 
representatives. Under these circumstances, the compliance 
determination requirements under paragraphs (c)(18)(i) through (iii) of 
this section would not apply to the NOX emission limit.
* * * * *
    (20) PM compliance dates for Domtar Ashdown Mill Power Boiler No. 
2. The owner or operator of the boiler must comply with the PM BART 
requirement listed in paragraph (c)(19) of this section by November 28, 
2016.
    (21) Alternative PM Compliance Determination for Domtar Ashdown 
Paper Mill Power Boiler No.2. If the air permit is revised such that 
Power Boiler No. 2 is permitted to burn only pipeline quality natural 
gas, this is sufficient to demonstrate that the boiler is complying 
with the PM BART requirement under paragraph (c)(19) of this section.
    (22) Emissions limitations for Entergy Independence Units 1 and 2. 
The individual emission limits for each unit are as listed in the table 
in this paragraph (c)(22) in pounds per million British thermal units 
(lb/MMBtu). The SO2 emission limits listed in the table as 
lb/MMBtu are on a rolling 30 boiler-operating-day averaging period.

------------------------------------------------------------------------
                                                           SO2 Emission
                          Unit                              limit (lb/
                                                              MMBtu)
------------------------------------------------------------------------
Entergy Independence Unit 1.............................            0.06
Entergy Independence Unit 2.............................            0.06
------------------------------------------------------------------------

    (23) Compliance dates for Entergy Independence Units 1 and 2. The 
owner or operator of each unit must comply with the SO2 
emission limits in paragraph (c)(22) of this section by October 27, 
2021.
    (24) Compliance determination and reporting and recordkeeping 
requirements for Entergy Independence Units 1 and 2. (i) For purposes 
of determining compliance with the SO2 emissions limit 
listed in paragraph (c)(22) of this section for each unit, the 
SO2 emissions for each boiler-operating-day shall be 
determined by summing the hourly emissions measured in pounds of 
SO2. For each unit, heat input for each boiler-operating-day 
shall be determined by adding together all hourly heat inputs, in 
millions of BTU. Each boiler-operating-day of the thirty-day rolling 
average for a unit shall be determined by adding together the pounds of 
SO2 from that day and the preceding 29 boiler-operating-days 
and dividing the total pounds of SO2 by the sum of the heat 
input during the same 30 boiler-operating-day period. The result shall 
be the 30 boiler-operating-day rolling average in terms of lb/MMBtu 
emissions of SO2. If a valid SO2 pounds per hour 
or heat input is not available for any hour for a unit, that heat input 
and SO2 pounds per hour shall not be used in the calculation 
of the applicable 30 boiler-operating-days rolling average. For each 
day, records of the total SO2 emitted that day by each 
emission unit and the sum of the hourly heat inputs for that day must 
be maintained by the owner or operator and made available upon request 
to EPA and ADEQ representatives. Records of the 30 boiler-operating-day 
rolling average for each unit as described in this paragraph (c)(24)(i) 
must be maintained by the owner or operator for each boiler-operating-
day and made available upon request to EPA and ADEQ representatives.
    (ii) The owner or operator shall continue to maintain and operate a 
CEMS for SO2 on the units listed in paragraph (c)(22) in 
accordance with 40 CFR 60.8 and 60.13(e), (f), and (h), and appendix B 
of 40 CFR part 60. The owner or operator shall comply with the quality 
assurance procedures for CEMS found in 40 CFR part 75. Compliance with 
the emission limits for SO2 shall be determined by using 
data from a CEMS.
    (iii) Continuous emissions monitoring shall apply during all 
periods of operation of the units listed in paragraph (c)(22) of this 
section, including periods of startup, shutdown, and malfunction, 
except for CEMS breakdowns, repairs, calibration checks, and zero and 
span adjustments. Continuous monitoring systems for measuring 
SO2 and diluent gas shall complete a minimum of one cycle of 
operation (sampling, analyzing, and data recording) for each successive 
15-minute period. Hourly averages shall be computed using at least one 
data point in each fifteen-minute quadrant of an hour. Notwithstanding 
this requirement, an hourly average may be computed from at least two 
data points separated by a minimum of 15 minutes (where the unit 
operates for more than one quadrant in an hour) if data are unavailable 
as a result of performance of calibration, quality assurance, 
preventive maintenance activities, or backups of data from data 
acquisition and handling system, and recertification events. When valid 
SO2 pounds per hour emission data are not obtained because 
of continuous monitoring system breakdowns, repairs, calibration 
checks, or zero and span adjustments, emission data must be obtained by 
using other monitoring systems approved by the EPA to provide emission 
data for a minimum of 18 hours in each 24-hour period and at least 22 
out of 30 successive boiler operating days.
* * * * *
[FR Doc. 2018-02145 Filed 2-9-18; 8:45 am]
BILLING CODE 6560-50-P
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